Well packer having a selectively positionable valve means



Dec. 16, 1969 wl o, BERRYMAN 3,483,921

WELL PACKER HAVING A SELECTIVELY POSITIONABLE VALVE MEANS Original FiledOct. 5. 196? 3 Sheets-Sheet l ,X7/ "i I/ f2 W////am 0. @enig/nav? I NVEN TOR. 45

Dec. E6, 1969 w. o. BERRYMAN 3,483,921

WELL PACKER HAVING A SELECTIVELY POSITIONABLE VALVE MEANS Original FiledOct. 5, 1967 3 Sheets-Sheet 2 I N VENTOR.

Dec,I 16, i969 w. o. BERRYMAN 3,483,92

WELL PACKEH HAVING A SELECTIVELY PSITIONABLE VALVE MEANS Original FiledOct. 5, 1967 3 Sheets-Sheet 3 45 W////am 0. Berry/77a j INVENTOR.

BY MMM/Mo? Armin/5y United States Patent O 3,483,921 WELL PACKER HAVINGA SELECTIVEIJY PUSITIUNABLE VALVE MEANS William 0. Berryman, Houston,Tex., assigner to Schlumberger Technology Corporation, Houston, Tex., acorporation of Texas Original application Oct. 5, 1967, Ser. No.673,175.

Divided and this application Bec. 16, 1968, Ser.

Int. Cl. E211) 23/06, 33/128 US. Cl. 166-128 7 Claims ABSTRACT F THEDISCLOSURE This is a division of application Ser. No. 673,175, filedOct. 5, 1967.

This invention relates generally to well tools used in well bores, andmore specifically to a well packer apparatus adapted to be set in a wellconduit and having a flow control valve which can be utilized to controlfluid flow in the well conduit.

In one aspect, the present invention provides a new and improved wellpacker apparatus having a ilow control valve and adapted to be loweredinto a well bore on a tubular running string, the flow control valvebeing selectively positionable in open or closed condition. Thus ou theone hand, the flow control valve can be closed to enable running-inunder pressure or to permit testing of the tubular string for leakageduring running. On the other hand, the ow control valve can be opened sothat the string can ll with well iluids during running.

Accordingly, the present invention comprises a well packer having amandrel with a ow passage, valve means for opening and closing thepassage, and a tubular valve actuating member sealingly slidable in theflow passage for conducting tluid and for moving the valve means betweenpositions opening and closing the passage to tluid flow. Releasablelocking means are provided which coacts with the actuating member andmandrel to relatively position the actuating means and mandrel such thatthe valve means can be positioned in open condition. Moreover, the valvemeans and actuating member are arranged for selective relativepositioning in a manner whereby the valve means is positioned in closedcondition. In either case, the actuating member can be manipulated torepetitively open and close the valve means upon release of the lockingmeans.

In another aspect, the present invention provides a new and improvedapparatus to enable selective uncoupling of tubular members in a wellbore. Where one member is telescoped within another member which isanchored in a well bore and constructed and arranged to be relativelymovable by longitudinal and rotational movement within the anchoredmember, the risk will be appreciated by those skilled in the art thatsedimentation or debris may collect between the members and can lodgeone member within the other. Should this occur, the members may becomestuck in the well and it is desirable to be able to release the onemember from the anchored member so that the one member can be removedfrom the well.

ice

Accordingly, the present invention provides a releasable safety couplingbetween members which can be released in a simple manner should themembers become lodged in the well. The safety coupling comprises a rstmember which can be rotated relative to a second member and means forrotatively coupling the members to one another. Clutch means is providedand arranged for movement between longitudinally spaced positions onsaid members for permitting relative rotation of said members in oneposition of said clutch means, and for securing said members togetherfor co-rotation in another position oi said clutch means. A third membercan be threadedly coupled to said iirst member in a manner to beunscrewed by co-rotation of said irst and second members relative tosaid third member. Thus it will be apparent that should said thirdmember become stuck in a well bore, said irst and second members can beuncoupled therefrom for withdrawal from the well.

The present invention has other aspects and advantages which will becomemore clearly apparent in connection with the following detaileddescription. Preferred embodiments are shown in the accompanyingdrawings, in which:

FIGURES 1A and 1B are longitudinal sectional views, with portions inside elevation, of an apparatus which embodies the principles of thepresent invention with parts in relative positions for lowering into awell bore, FIGURE 1B forming a lower continuation of FIG- URE 1A;

FIGURE 2 is an isometric view of the rotary valve element;

FIGURE 3 is a fragmentary developed view of a coupling mechanism usedwith the present invention;

FIGURE 4 is a fragmentary developed view to illustrate the torquetransmission structure between the eX- tension and valve sleeve inaccordance with the present invention;

FIGURE 5 is a fragmentary developed view of the extension slot used withthe present invention;

FIGURE 6 is a cross section on line 6-6 of FIGURE 1A; and

FIGURES 7A and 7B are views similar to FIGURES 1A and 1B except withvarious parts of the apparatus in their cooperative positions when setin a well bore.

With initial reference to FIGURES 1A and 1B, apparatus which willillustrate the principles of the present invention includes a mechanicalsetting tool A and a well packer B having a valve system C. The settingtool A is utilized in setting the packer B in a well ybore so that thepacker B can function to pack-olf the well bore. The valve system Ccontrols fluid communication to the well bore below the packer B. Theentire apparatus can be lowered into the well on a running-in string 10of tubing or drill pipe which provides a iluid conduit extending to thetop of the Well, as well as a mechanical member which can be manipulatedat the top of the well bore to effect operation of the setting tool Aand the valve assembly C.

As shown in FIGURE 1B, the packer B has a central body or mandrel 11having a bore 12 which provides a lluid passageway and further has alower guide portion 13 which supports lower slips 14. The slips 14 cantake any desired form, such as frangible, segmented, or integraleXpansible type slips. A lower expander cone 15 is arranged to shift thelower slips 14 outwardly and a conventional packing structure 16surrounds the mandrel 11 between the lower expander cone and an uppereX- pander cone 17. Typical anti-extrusion rings 18, 18a can confine theend portions of the packing 16, and shear pins 19, 19a 0r other suitablemeans can releasably couple the expander cones 15 and 17 to the mandrel11 to control the relative motion sequence between parts in any desiredmanner. A conventional split ratchet ring 20 is 3 arranged between theupper expander cone 17 and the mandrel 11 andV cooperates with externalteeth 21 on the mandrel to trap compression loading in the packingstructure 16 when the well packer B is set.

The lower guide portion 13 of the mandrel 11 is constituted as a valvebody having a central flow passage 24 which is closed in a fluid tightmanner at its lower end by a plug 25. Diametrically opposed side ports26 in the valve body 13 are provided to communicate with the wellannulus below the packing element 16. A valve sleeve 27 is locatedwithin the passage 24 adjacent to the side ports 26 and is arranged formovement between various rotational positions about the longitudinalaxis of the mandrel 11 to control iiuid ilow from the passage 24 throughthe side ports 26. In one rotational position, lateral ports 28 in thevalve sleeve 27 are aligned with the side lports 26 in the valve body 13to permit uid ow. In other rotational positions of the valve sleeve 27,the ports 26 and 2S are not in registry and the passage 24 is closed touid flow in either direction.

As shown in FIGURE 2, the valve sleeve 27 is generally tubular in formand has appropriate external grooves for a seal structure which caninclude upper and lower annular seals 29 and 30 which are connected byvertically extending seals 31 and 32 located on either side of the ports28. With this type of seal coniguration, the side seals 31 and 32together with the seal portions 33 and 34 above and below the ports 28prevent fluid ow through the ports, while the entirety of the upper andlower seals 29 and 30 precludes tlow through the body ports 26. In thealternative, it will be appreciated that the seal arrangement couldinclude face seals which surround the sleeve ports 28 to prevent ow ineither direction through the sleeve ports, along with upper and lowerannular sleeve seals above and below the face seals to prevent flow ineither direction through the body ports 26. Radially inwardly extendingpins 35 on the valve sleeve 27 provide a means for applying rotationforce or torque to the valve sleeve 27 to rotate it between its variouspositions.

With particular reference to FIGURE 1A, the setting tool assembly Aincludes a central operating mandrel 33 having an open bore 39 and whichcan be connected to the lower end of the tubing string by a threadedcollar 40 or the like. The lower end portion of the operating mandrel 38is provided with a swivel connection 41 to a tubular extension assemblywhich includes an enlarged sub 42 arranged to engage the upper end ofthe packer mandrel 11 and a tubular extension y45 which telescopeswithin the bore 12 of the packer mandrel. The sub 42 and extension 45are threaded together at 43 in a fluid tight manner. A swivel sleeve 44is coupled to the upper portion of the sub 42 and has an inwardlyextending shoulder section 46 forming an annular space 47 whichrotatably received an outwardly extending section 4S on the operatingmandrel 38. Accordingly, it will be apparent that the extension 45 andsub 42 can turn or rotate relative to both the operating mandrel 38 andthe tubing 10. Appropriate seals such as O-rings 49 and 56 can beprovided, the lower seal 5t) preventing uid leakage from the bore of themandrel 38 at the swivel connection 41, and the upper seal 49 protectingthe swivel connection from ambient well iiuids and debris.

The extension 45 is telescoped within the bore of the packer mandrel 11and has arcuate coupling lugs 52 which can engage within an elongateinternal mandrel recess 53. The recess 53, shown in an inside developedview in FIGURE 3, is open to the top of the packer mandrel 11 byvertically extending slots 54 and 55 located on circumferentiallyopposite sides of the ybore of the mandrel. Thus, the coupling lugs 52can be inserted into the recess 53 via the slots 54 and 55 and rotationof the extension 45 relative to the mandrel 11 will position the lugs 52underneath mandrel shoulders 56 formed between the slots. With thisrelationship of parts, engagement of the coupling lugs 52 with theshoulders 56 will limit upward movement of the extension relative to themandrel 11, and engagement of the sub 42 with the upper end surface ofthe mandrel 11 will limit downward movement. Accordingly, when the lugs52 are underneath the shoulders 56, the extension 45 is coupled forlimited reciprocating motion relative to the mandrel 11, and when thelugs are aligned with the slots 54, 55. the extension can be insertedwithin, or withdrawn from, the bore 12 of the mandrel 11.

The lower end of the extension 45 is open at 57 and side ports 55 areprovided for fluid flow. When the extension 45 is telescoped within thepacker mandrel 11 as shown in FIGURE 1B, the lower end portion 59 of theextension 45 is located within the valve sleeve 27. A torque sleeve 69is threaded onto the lower end portion 59, and properly positionedthereon as by a screw 61 or the like and has upwardly extending sideguide slots 62 which are dared and open at the lower end of the sleeve60. The slots 62 receive the valve sleeve pins 35 so that rotation or"the extension 45 will impart corresponding rotation to the valve sleeve27. Each of the side slots 62, one or' which is shown in developed viewin FIGURE 4, has a longitudinal portion 63 of suicient vertical extentwhereby the extension 45 can be moved upwardly and downwardly apredetermined amount and still be co-rotatively coupled to the valvesleeve 27. Moreover, the slots 62 each have an upper circumferentiallyenlarged portion 64 to permit the valve sleeve 27 to be rotated to acertain extent relative to the extension 45 and in a direction which isopposite to its normal direction of rotation for purposes which will behereafter explained. The upper end of the torque sleeve can be made toterminate below an outwardly extending shoulder 65 on the extension 45to provide an annular recess in which a seal structure 66 is located.The seal structure 66, which can take many forms, is shown as one ormore metallic rings 67 having inner and outer grooves which receivesuitable seals 68 and 69. Thus arranged, the seal structure 66 preventsfluid leakage between the packer mandrel 11 and the extension 45 whenthe latter is telescoped within the former.

Upper slip segments 72 are mounted at the upper end portion of thepacker mandrel 11 adjacent to the upper expander cone 17. The segments72 have upward facing wickers or teeth 73 on their outer peripheries, aswell as inner inclined surfaces 74 which are engageable with outerinclined surfaces 75 on the expander cone 17 for shifting the segmentsoutwardly into gripping engagement with well casing. The extension sub42 and the packer mandrel 11 are respectively provided with annulargrooves 76 and 77 and the slip segments 72 can have correspondingshoulders 78 and 79 which engage within the grooves to limit verticalmovement of the slip segments in their retracted positions as well asinitially coupling the extension sub 42 in xed relation to the packermandrel 11. A retainer sleeve 80, which forms a part of the setting toolA, extends downwardly in encompassing relation over upper portions 81 ofthe slip segments to retain them inwardly in retracted positions as longas the retainer sleeve occupies the relative position shown in FIGURES1A and 1B. It will be appreciated that due to the engaging conditions ofthe shoulders 7S and 79 within the grooves 76 and 77, and to the holdingaction of the retainer sleeve 80, the slip segments 72 are quite rigidlyheld inwardly in retracted positions to prevent any likelihood ofpremature setting during lowering into a well.

Further to the setting tool assembly A, a control sleeve 88 (FIGURE 1A)is slidably and co-rotatively secured to the operating mandrel 3S bysplines S9 or the like. The control sleeve 8S is initially locked in anupper position on the ymandrel 38 by several latch lugs 91B which engagein a mandrel detent 91. A drag mechanism 92 including a tubular cage 93is initially secured in a lower position on the control sleeve bycoengaging right-hand threads 94. Typical drag blocks 95 are carried bythe cage 93 and are urged outwardly by coil springs 96 to frictionallyengage casing and resist motion in a conventional manner. An

inner surface 97 on the cage 93 holds the latch lugs 90 inwardly inengagement with the mandrel detent 19 while the parts are in therelative positions for lowering into a well bore.

The slip retainer sleeve 80 extends downwardly from the cage 93 toencompass the upper end portions 81 of the upper slip segments 72 as waspreviously described. When desired, it will be appreciated thatright-hand rotation of the operating mandrel 38 by the running-in stringwill rotate the control sleeve 88 relative to the drag mechanism 92,and, due to the interengagement of the threads 94, cause the dragmechanism and the retainer sleeve 80 to feed upwardly along the controlsleeve 88, thereby removing the retainer sleeve from encompassingrelation to the upper portions of the slips 72. Upward feeding of thedrag mechanism 92 will also position an internal cage recess 100opposite the latch lugs 90 and permit them to move outwardly and releasefrom the mandrel detent 91, thereby permitting upward movement of theoperating mandrel 38 relative to the control sleeve 88 and the dragmechanism 92.

A slip setting sleeve 101 extends downwardly from the control sleeve 88and terminates in spaced relation to the upper portions 81 of the slips72. When the retainer sleeve 80 is removed upwardly, the slips 72 arenot restrained and can move outwardly to engage the well casing. Outwardmovement of the slips will, of course, remove the shoulders 78 and 79from engagement with the mandrel and sub grooves 76 and 77 and there byuncouple the packer mandrel 11 from the extension assembly. With thiscondition of parts, the extension 45 can telescope upwardly relative tothe packer mandrel 11 until the coupling lugs 52 engage the recessshoulders 56. Then upward extension movement will shift the packermandrel 11 upwardly relative to the setting sleeve 101, the latter partnot moving upward by virtue of the engagement of the friction dragblocks 95 with the well casing. Accordingly, it will be appreciated thatthe slip segments 72 cannot move upwardly due to the holding action ofthe setting sleeve 101, and that the expander cone 17 can be movedupwardly and behind the slips 72 to shift them outwardly into firmanchoring engagement with the well casing, Once the upper slips 72 areset, the expander cone 17 cannot rnove any further upwardly andcontinued upward movement of the mandrel 11 will advance the lower conetoward the upper cone to expand the packing 16. The lower slips 14 areshifted over the lower expander cone 15 and outwardly into grippingengagement with the well casing. The ratchet ring 20 will lock the partsin expanded position in conventional manner.

ln response to upward and downward motions of the extension relative tothe packer mandrel 11 occasioned by like motions imparted to therunning-in string 10 once the packer B is set, the extension 45 iscaused to rotate through various rotational positions due tointerengagement of index pins 104, extending inwardly within the bore ofthe mandrel 11, with an extension slot system 105 to be described below.Rotation of the extension 45 within the packer mandrel 11 serves theprimary function of selectively rotating the valve sleeve 27 betweenopen and closed positions. As shown in plain view in FIGURE 5, the slotsystem 105 is formed about the periphery of extension 45 and includesvertically disposed entrance and exit slots 106 and 107 located onopposite sides of the extension. inasmuch as the slot system issymmetrically arranged around the circumference of the extension 45, forpurposes of brevit, only onehalf of the total slot system structure willbe described and it will he appreciated that each slot portion mentionedhereafter has an identical counterpart location on the opposite side ofthe extension. Between these entrance and exit slots 106 and 107 areupper pockets 108 and 109, the left upper pocket 108 being located, forexample, about degrees from entrance and exit slot 106 and the rightupper pocket 109 being located, for

example, about 40 degrees from entrance and exit slot 107. Aninter-mediate pocket 110 is located between the upper pockets 108 and109 and can be located about 50 degrees from the left upper pocket 108.The entrance and exit slot 106 is connected to the upper pocket 108` bya channel 111 which extends upwardly and to the right, and the upperpocket 108 is connected to the intermediate pocket 110 by a channel 112which extends downwardly and to the right. The intermediate pocket 110is connected to the upper pocket 109 by a channel 113 which extendsupwardly and to the right like channel 111, and the upper pocket 109 isconnected to the entrance and exit slot 107 by a channel 114 whichextends downwardly and to the right like channel 112. The intersectionsof the channels 111 and 112, and 113 and 114, are located somewhat tothe left of the respective centers of the upper pockets 108 and 109 sothat the index pin 104 is constrained to enter the channel 112 whenleaving pocket 108, and channel 114 when leaving pocket 109. Moreover,the intersection of channels 112 and 113 is located somewhat to the leftof the intermediate pocket 110 so that the index pin 104 will enter thechannel 113 when leaving the pocket 110.

It will be apparent that the slot system provides a guideway in whichthe pins 104 engage to cause a predetermined sequence of rotationalmovements of the extension 45 relative to the mandrel 11 in response toupward and downward Amotions of the extension. Thus, movement of theindex pin 104 from entrance and exit slot 106 to the left upper pocket108 Will cause the extension 45 to rotate about 50 degrees in aclockwise direction (viewed from above) within the packer mandrel 11,such rotation being occasioned by engagement of the upper inclined wall115 of channel 111 with the index pin. Movement of the index pin 104from the upper pocket 108 to the pocket 110 will cause another 5.0degrees rotation of the extension 45 when the lower inclined wall 116 ofthe channel 112 engages the index pin 104, and further movement from thepocket to the right upper pocket 109 will cause an additional 40 degreesrelative rotation when the index pin engages the upper inclined wall 117of the channel 113. Finally, ymovement of the index pin 104 from theright upper pocket 109 down through the channel 114 with inclined lowerwall 118 and out of the entrance and exit slot 107 will effect another40 degrees relative rotation of the extension 45 for a total of l80`degrees. Each increment of extension rotation will cause a correspondingamount of rotation of the valve sleeve 27 by virtue of engagement of thevalve sleeve pins 35 with the walls 63a of the slots 62 in the torquesleeve 60. Of course the direction of rotation of the extension 45 andthe valve sleeve 27 is a function of the slot system 105 and, althoughthe arrangement shown is preferred, it will be appreciated that the slotsystem 105 could be arranged in reverse manner so that the extension andvalve will rotate in the left-hand direction.

The coupling lugs 52 on the extension 45 are vertically aligned relativeto the entrance and exit slots 106 and 107, and the mandrel recessopenings 54 and 55 (FIGURE 3) aligned relative to the index pins 104,such that when the index pins 104 engage within the entrance and exitslots, the coupling lugs 52 are vertically aligned with the mandrelrecess openings and can readily pass into, and out of, the mandrelrecess '53. When the index pins 104 engage the upper wall surfaces 118of the channels 111 which are inclined upwardly and to the right, theextension 45 is caused to rotate or swivel in the clockwise direction toposition the coupling lugs 52 underneath the mandrel shoulders 56. The.lugs 52 will remain in positions underneath the mandrel shoulders 56 aslong as the entrance and exit slots 106, 107 are not aligned with theindex pins 104. The entrance and exit slots 106 and 107 are alsocircumferentially located relative to the torque sleeve slots 60 so thatwhen the index pins 104 are within the slots 106 and 107, and thus whenthe coupling lugs 52 can pass through the recess openings 54 and 55, thevalve sleeve 27 is always in a closed rotational position. The bosses126' formed between the entrance and exit slots 166 and 107 can havelower converging cam surfaces 121 and 122 to insure that the mandrelindex pins 164 will enter one or the other of the slots 105 and 167regardless of the initial rotational position of the extension 45relative to the packer mandrel 11 when the extension is inserted.Moreover, the pins 1014 can have flattened peripheral portions to reducebearing loads as the pins work within the slot system 105.

Should it ever be desired to disconnect the setting tool A from the wellpacker B, leaving the extension 45 within the bore of the packer mandrel11, for example, where the extension 45 has become lodged within themandrel by sedimentation or junk in the well, a safety feature isprovided for this purpose. With particular reference to FIGURES 1A and6, the swivel section 48 has a reduced diameter portion 125 which isexternally threaded with buttress type teeth 125 facing upwardly. Aclutch ring 127 is cut through at 129 and is capable of suflicientlateral expansion and contraction for ratcheting action over the teeth126 in an upward direction. A longitudinally extending key 130 on theswivel sleeve 44 engages within the cut 129 to co-rotatively andslidably secure the ring to the sleeve. The section 48 further has anupper outwardly extending annular shoulder 131 having an inwardly andupwardly inclined lower face 132 which is shaped in complimentary mannerto the inclined upper end surface 133 of the clutch ring 127.

It will be appreciated that due to the conguration of the slot system105 and its coaction with the indexing pins 104, the extension 45 willalways rotate relative to operating mandrel 35 in the same direction,for example, with the slot arrangement shown in FIGURE 5, in theclockwise or right-hand direction viewed from above. Accordingly, thethreads 126 and 128 on the section 125 and clutch ring 127 respectivelycan be formed as right-hand threads. Thus, clockwise rotation of theswivel sleeve 44 and the clutch ring 127 relative to the operatingmandrel 38 will tend to cause downward feeding of the clutch ring.However, by virtue of engagement of the ring 127 with the sub shoulder134 as shown in FIGURE lA, the clutch ring will remain stationary andmerely ratchet upwardly over the threads 126 in response to continuedrotation of extension assembly relative to the operating mandrel duringnormal operation of the tool. However, it' the operating mandrel 38 isrotated in a clockwise or right-hand rotation of the running-in string19 at the top of the well bore, the clutch ring 127 will feed upwardlyalong the threads 126 until the inclined surfaces 132 and 133 engage,thereby exerting inward force on the clutch ring and clutching theoperating mandrel 38 to the swivel sleeve 44 since the clutch ringcannot ratchet downwardly along the threads 126. The clutch ring 127 canalso have a lower annular shoulder 134 which is sized for snugengagement within the bore of the sleeve `44 when the ring is in itsupper position to further hold the ring inwardly in gripping engagementwith the threads 126. Thus, continued rotation in the same direction ofthe running-in string 19 will effect unscrewing of the threads 43between the swivel sub 42 and the extension 45, which threads are formedas left-hand threads, so that the entire setting tool A except for theextension 45 can be withdrawn from the well.

OPERATION In operation, the parts are assembled as shown in the drawingswith the extension 45 telescoped within the packer mandrel 11. The slips15 and 72 and the packing 16 are in normally retracted positions, theupper slips 72 being retained inwardly by the retainer sle'eve Si). The

drag blocksSS can slide along in frictional engagement with the weilcasing as the tool is lowered into a well bore to settiny depth. If itis desired to lower the packer with the valve sleeve 2'7 in openconditions so that the running-in string 19 can lill with well iluidduring lowering. the extension is merely inserted into the packermandrel 11 during assembly and the index pins 104 will probably indexthe extension until the pins are in the left ripper pockets ll, orpositions D, FIGURE 5. rThis rotational position of the extension 45will properly align the sleeve and body ports 28 and 26 in registry withone' another` rfhe shoulders 78 and 79 on the respective' upper slipsegments 72 are engaged within the extension and mandrel grooves 76 and77 so that the extension 45 cannot move longitudinally with respect tothe mandrel 11. Thus the valve sleeve 27 will remain in open conditionduring lowering. On the other hand, if it is desired to run the tool inthe well with the valve sleeve v27 in closed condition, the plug 25 atthe lower end of the mandrel 11 can be conveniently removed to gainaccess to the valve sleeve 27 and the valve sleeve rotated relative tothe extension 45 to position the pins 35 within the enlarged slotportions 64 on the torque sleeve 60. This will orient the valve sleeve27 in a rotationally closed position, which enables tubing testing bypressurizing the string during lowering, as well as running the packerinto the' well under pressure. Inasmuch as the valve sleeve 27 is alwaysrotated in the same direction by the extension 45, the enlarged portions64 have no effect on the operation of the valve sleeve 27 after the wellpacker is set. In other words, the straight sides 63a of thelongitudinal slot portion 63 always engage the sleeve pins 35 to rotatethe valve sleeve.

When it is desired to set the packer B, the running-in string 10 isfirst rotated a number of turns to the right. Since the drag mechanism92 cannot rotate due to engagement of the drag blocks 95 with thecasing, the control sleeve 88 will be rotated relative to the dragmechanism 92 with resultant upward feeding of the retainer sleeve Stbout of encompassing relation to the upper portions 81 of the upper slips72. In actuality, the entire apparatus in the well except for the dragmechanism 92 and retainer sleeve Sil will be rotated by the running-instring 10. When the retainer sleeve moves suiciently upwardly, the slips77 are free to move outwardly and the lower end of the setting sleeve101 is cleared for engagement with upper end surfaces of the slips 72.The cage recess 100 is now positioned adjacent to the latch lugs so thatthe lugs can move outwardly and release from the mandrel detent 91. Theoperating mandrel 38 is thus free to be moved upwardly relative to thecontrol sleeve 88, the drag mechanism 92 and the setting sleeve 101.

The running-in string 10 is then elevated to set the packer B. When theslips '72 are released, as previously described, the extension 45 canmove upwardly to a limited extent relative to the packer mandrel 11. Asthis relative movement occurs, the extension 45 is rotated as the indexpins 104 move within the intermediate pockets 110, or positions E,FIGURE 5. This rotation of the extension also positions the couplinglugs 52 underneath and in engagement with the mandrel recess shoulders56, the lugs moving from positions G to -positions H as shown in FIGURE3. If the valve is initially open, rotation of the extension 45 willalso cause corresponding rotation of the valve sleeve 27 to closedposition. On the other hand, if the valve sleeve 27 is initially closedduring lowering, rotation of the extension 45 will have no effect on thevalve sleeve because the enlarged slot portions 64 in the torque sleeve6G will permit this extension rotation to occur without impartingcorresponding rotation to the valve sleeve. Thus, the valve sleeve 27will remain in closed position.

inasmuch as the coupling lugs 52 are moved into engagement with themandrel shoulders 56, continued upward movement of the extension 45 willelevate the packer mandrel 11, and thus the upper expander cone 17,toward the lower end surface of the setting sleeve 101. The slips 72will thus be shifted outwardly into gripping engagement with the casing,the holding force of the drag blocks 95 being transmitted through thecage 93, threads 94, control sleeve 88 to the setting sleeve 101 toprevent its upward movement. The slips 72 will accordingly be heldagainst upward movement by the setting sleeve 101 and sufficient upwardmovement of the packer mandrel 11 will bring the expander core 17 behindthe slips 72 to shift them outwardly into gripping engagement with thecasing as shown in FIGURE 7B. When the upper slips 72 grip the casing,the upper expander cone 17 cannot move any further upwardly, andcontinued upward movement of the packer mandrel 11 will cause expansionof the packing element 16 and then shifting of the lower slips 14 overthe lower expander cone 15. The external body teeth 21 will ratchetthrough the ratchet ring 20 and the ring will trap the mandrel 11 in thehighest position to which it is moved. Accordingly, the packing andslips are locked in expanded positions and when a predetermined upwardstrain is taken on the running-in string, the packer B will be firmlyset.

After thus setting the packer B, the weight of the running-in string 10is slacked off. This will occasion downward movement of the extension 45within the packer mandrel 11 with consequent rotation of the extensionand the valve sleeve 27 until the index pins 104 are within the rightupper pockets 109 of the slot system, positions E in FIGURE 5. The valvesleeve 27 is still in one of its closed rotational positions.Accordingly, the running-in string 10 is closed-oli at its lower end andcan be pressure tested for leakage at this time. The weight of therunning-in string 10 can be conveniently imposed upon the packer B sothat pressurizing the string 10 will not cause the extension as to belifted upwardly by the pressure. The feature of being able to imposetubing weight on the tool when testing tubing is an important advantageover packers of this type having reciprocating sleeve valves because theimposition of tubing weight may open the valve systems of these packers.

After such testing, the running-in string 10 is simply picked up at thesurface to disengage the extension 45 from within the bore of the packermandrel 11. As the extension 45 is moved upwardly, the index pins 104will cause the extension and the valve sleeve 27 to rotate again as theindex pins move within the entrance and exit slots 107. The valve sleeve27 is still closed. In this relative rotational position of parts thecoupling lugs 52 are moved from positions K, FIGURE 3, into verticalalignment with the mandrel recess openings 54, 55. Accordingly, theextension 45 is conditioned to ybe withdrawn from the bore of the packermandrel 11. It will be noted that whenever the extension 45 iswithdrawn, the valve sleeve 27 is always left in a closed rotationalposition, whereby the well packer B completely bridges the well bore toprevent fluid tiow in either longitudinal drection.

To perform a pressure operations such as squeeze cementing, theextension 45 is reinserted within the bore 12 of the packer mandrel 11by downward movement of the running-in string 10. Regardless of theinitial random rotational position of the extension 45, the bosses 120and the lower cam surfaces 121 and 122 will cooperate with the indexpins 104 to properly orient the extension 45 such that the index pinsare vertically aligned within the entrance and exit slots 106 and 107.With the slots 106 and 107 thus aligned, the coupling lugs 52 are alsoaligned with the mandrel recess openings 54, 55, and the side slots 62in the valve torque sleeve 60 are properly positioned with respect tothe valve sleeve pins 35 so that the lower end portion 59 of theextension can be lowered inside the valve sleeve 27. When the extension45 has moved suiciently downwardly within the bore of the packer mandrel11, the index pins 104 will engage the upper inclined surfaces 115 ofthe channels 111 and cause the extension and the valve sleeve 27 torotate during further downward movement until the index pins are withinthe left upper pockets 108. As this rotation occurs, the valve sleeveports 28 will become radially aligned with the valve `body ports 26 toopen the valve. The coupling lugs 52 are also rotated to positionswithin the mandrel recess 53 such that the lugs are underneath therecess shoulders 56. With the valve open, cement slurry can be displacedthrough the running-in string 10 and out into the well bore below thepacker.

When suthcient displacement has occurred and it is desired to trap thesqueeze, e.g., to retain the cement slurry at developed pressures belowthe packer B, the valve sleeve 27 can be moved to a rotationally closedposition by simply picking the running-in string 10 upwardly to indexthe extension 45 until the index pins 104 are within the intermediatepockets 110, thereby rotating the valve sleeve 27 to closed position.The coupling lugs 52 will engage the mandrel shoulders 56 to positivelyprevent separation of the extension from the mandrel 11, therebyenabling complete control of tubing and annulus pressures. Thus it will`be appreciated that adequate annulus pressures can be maintained toprevent dumping cement into well bore when the extension 45 is purposelydisengaged. The extension 45 can be withdrawn from the packer mandrel11, leaving the valve sleeve 27 in closed position, by imparting a pairof vertical motions to the running-in string 107 one downward, and oneupward. The corresponding reciprocation of the extension 45 will causethe index pins 104 to traverse the channels 113 and 114 and into theentrance and exit slots 105, whereupon the coupling lugs 52 arevertically aligned with the mandrel recess openings 54, and theextension 45 is free for upward movement, leaving the valve sleeve 27 inclosed condition. The setting tool A can be withdrawn from the well, orconventional circulation or reverse circulation procedures can beundertaken. Of course, the extension 45 carl be reinserted within thepacker mandrel 11 for further operations as desired.

Although the packer B is disclosed as settable on the mechanical settingtool A, it will be appreciated that the packer can Ibe set by thevarious wireline or other setting tools which are conventional n theart. In case of wireline setting, of course other upper slips such asconventional fraugible or solid type slips, can be utilized, and theplug25 at the lower end of the mandrel 11 is provided with internalthreads for connecting to the tension member of the setting tool. Thusit will be apparent that apparatus of the present invention is quiteversatile and can be used for a variety of down hole applications aswill be apprciated by those skilled in this art.

Since certain changes or modifications may be made in the presentinvention by those skilled in the art without departing from theconcepts involved, it is intended that the appended claims cover allsuch changes or modifications falling within the true spirit and scopeof the present invention.

I claim:

1. A well tool comprising: a valve body having a flow passage; valvemeans in said valve body arranged for rotational movements betweenpositions opening and closing said iiow passage; valve actuating meansextendible into said flow passage; normally engageable means forreleasably coupling said actuating means to said valve means to enablerotation of said valve means by said actuating means in one rotationaldirection; and means for disengaging said normally engageable means topermit selective rotation of said valve means relative to said actuatingmeans in the opposite rotational direction.

2. The well tool of claim 1 wherein said normally engageable meansincludes recess means in said actuat- 1 1 ing means, and drive means forsaid valve means extending into said recess means.

3. The well tool of claim 2 -wherein said disengaging means comprises anenlargement of said recess means in which said drive means can bepositioned.

4. In combination with a well packer apparatus having a mandrelproviding a flow passage and valve means mounted for rotational movementin said ow passage, valve actuating means sealingly slidable in saidflow passage and movable longitudinally and rotationally therein, meansfor translating longitudinal movement of said actuating means torotational movement thereof, means for coupling said actuating means andvalve means whereby rotational movement of said actuating means impartscorresponding rotational movement to said valve means, and releasablemeans for locking said actuating means to said mandrel in a longitudinalposition of said actuating means corresponding to a selected rotationalposition of said valve means with respect to said ow passage.

5. The combination of claim 4 wherein said releasable means includesnormally retracted means moveable between retracted and expandedpositions relative to said mandrel and engageable with said actuatingmeans and mandrel when in said retracted positions.

6. The combination of claim 4 wherein said releasable means includesnormally retracted slip means moveable between retracted and expandedlpositions relative to said mandrel and engageable with said actuatingmeans and mandrel when in said retracted positions, and wherein saidcombination further includes means for retaining said normally retractedmeans slip in retracted positions. and means for disabling saidretaining means.

7. The combination of claim 4 wherein said coupling means includes meansto enable rotation of said valve means relative to said actuating meansto another selected rotational position of said valve means with respectto said flow passage.

References Cited UNITED STATES PATENTS 2,998,805 9/1961 Usab 251-58 K3,306,366 2/1967 Muse 166-128 l( 3,334,691 8/1967 Parker 166-1523,351,133 11/1967 Clark et al. 166-226 3,356,140 12/1967 Young 166-1283,386,701 6/1968 Potts 166-226 K 3,433,304 3/1969 Pavlas 166-226 DAVIDH. BROWN, Primary Examiner U.S. Cl. X.R. 166-124, 226

